GB2151359A - Method for determining source and receiver statics in marine seismic exploration - Google Patents
Method for determining source and receiver statics in marine seismic exploration Download PDFInfo
- Publication number
- GB2151359A GB2151359A GB08429259A GB8429259A GB2151359A GB 2151359 A GB2151359 A GB 2151359A GB 08429259 A GB08429259 A GB 08429259A GB 8429259 A GB8429259 A GB 8429259A GB 2151359 A GB2151359 A GB 2151359A
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- GB
- United Kingdom
- Prior art keywords
- seismic
- source
- refraction
- signals
- statics
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Granted
Links
- 230000003068 static effect Effects 0.000 title claims description 53
- 238000000034 method Methods 0.000 title claims description 17
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 9
- 230000015572 biosynthetic process Effects 0.000 claims description 6
- 238000012937 correction Methods 0.000 claims description 6
- 230000001934 delay Effects 0.000 claims description 5
- 238000010304 firing Methods 0.000 description 12
- 238000005755 formation reaction Methods 0.000 description 5
- 238000012935 Averaging Methods 0.000 description 3
- 239000013049 sediment Substances 0.000 description 2
- GRYSXUXXBDSYRT-WOUKDFQISA-N (2r,3r,4r,5r)-2-(hydroxymethyl)-4-methoxy-5-[6-(methylamino)purin-9-yl]oxolan-3-ol Chemical compound C1=NC=2C(NC)=NC=NC=2N1[C@@H]1O[C@H](CO)[C@@H](O)[C@H]1OC GRYSXUXXBDSYRT-WOUKDFQISA-N 0.000 description 1
- 230000002547 anomalous effect Effects 0.000 description 1
- 230000002301 combined effect Effects 0.000 description 1
- 238000009795 derivation Methods 0.000 description 1
- 230000000694 effects Effects 0.000 description 1
- 230000008030 elimination Effects 0.000 description 1
- 238000003379 elimination reaction Methods 0.000 description 1
- ZZUFCTLCJUWOSV-UHFFFAOYSA-N furosemide Chemical compound C1=C(Cl)C(S(=O)(=O)N)=CC(C(O)=O)=C1NCC1=CC=CO1 ZZUFCTLCJUWOSV-UHFFFAOYSA-N 0.000 description 1
- 238000005259 measurement Methods 0.000 description 1
- SYHGEUNFJIGTRX-UHFFFAOYSA-N methylenedioxypyrovalerone Chemical compound C=1C=C2OCOC2=CC=1C(=O)C(CCC)N1CCCC1 SYHGEUNFJIGTRX-UHFFFAOYSA-N 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 230000003252 repetitive effect Effects 0.000 description 1
- 101150117735 sel-10 gene Proteins 0.000 description 1
Classifications
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
- G01V1/38—Seismology; Seismic or acoustic prospecting or detecting specially adapted for water-covered areas
- G01V1/3808—Seismic data acquisition, e.g. survey design
-
- G—PHYSICS
- G01—MEASURING; TESTING
- G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
- G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
- G01V1/28—Processing seismic data, e.g. for interpretation or for event detection
- G01V1/36—Effecting static or dynamic corrections on records, e.g. correcting spread; Correlating seismic signals; Eliminating effects of unwanted energy
- G01V1/362—Effecting static or dynamic corrections; Stacking
Landscapes
- Life Sciences & Earth Sciences (AREA)
- Physics & Mathematics (AREA)
- Engineering & Computer Science (AREA)
- Remote Sensing (AREA)
- Acoustics & Sound (AREA)
- Environmental & Geological Engineering (AREA)
- Geology (AREA)
- General Life Sciences & Earth Sciences (AREA)
- General Physics & Mathematics (AREA)
- Geophysics (AREA)
- Oceanography (AREA)
- Geophysics And Detection Of Objects (AREA)
Description
1
SPECIFICATION
Method for determining source and receiver statics in marine seismic exploration 5: 1 1:
A_ This invention relates to marine seismic explo ration and more particularly to a method for determining source and receiver statics. - A majoriproblem in -seisrnic, exploration has been the estimation of time delays under - source and receiver positions due to weather ing, elevation,-and shallow velocity changes.
Particularly in some marine exploration areas severe time delays can be caused by the existence of a variety of subaqueous features 80 and other sea floor irregularities. Such aribma lies generally lie immediately below the water bottom and contain - sediffidrits having abnor mally low velocities relative to normal sedi- ', merits at shallow depths. These time delays' 85 are often considered together and called -sta tic errors',' and the corrections necessary to correct seismic traces for these errors'are,; called ---static. corrections- or simply -statics-.
-The widespread use of.multiple coverage seismic profiling and the stacking of multifod common depth point data as described in --CommonReflection Point, HorizontaA Data Stacking Techniques" by W..Harry Mayne, "Geophysics", Vol. XXVII, No. 6, Part 2 ' ' (Dec., 196 1), pp. 927-938, requires the elimination of these static errors. Several methods are known for determinifig these. static errors, one of which is described in ---TheApp lication -and Limitations of Automatic 100 Residual Static Correction Techniques- by B. M. Irving and J. K. Worley, presented at the 39th Annual International Meeting of the Society of Exploration Geophysicists in Calgary,- Alberta, Canada. Such a method, as well as others, provides a means of resolving the static estimates into source statics and re.: ceiver statics. It is these two components, source statics and receiver statics, which are utilized to correct the seismic data prior to common depth point stacking., The present invention is directed to a method for determining source and receiver statics at a marine exploration site having erratic low velocity layering below the water bottom.
In accordance with the present invention, there is provided a method of marine seismic exploration comprising the steps of fixing a seismic energy source and a seismic 'energy detector on the water bottom at a point offset from a line of marine exploration; traversing the line of marine exploration With a' marine vessel towing a seismic-eriergy source and a seismic marine cable including a plurality of spaced hydrophones; generating seismic energy from the towed seismic energy source-to produce a seismic reflection signal that is detected by the plurality of hydrophones on the seismic marine cable and a first seismic GB 2 151 359A 1 refraction signal that is detefed by the'fi,ed seismic energy- detector, the, f,i,rst. seismic refraction signal ihdiiidi - n - 9 a source statics attributable to time;'deia"y in the near surfac earth formation directly below the towed seismic energy source;'subsequently g'endating'seismic.energy frdm'the'fix'ed seism---ic 'energy' source to produce a'second 'seisrdic refraction signal that is detectedly each Of the plu'r-'ality of hydrophones on fh6'seismic' rharine &able, the second seismic refrabtion 'signal including a receiver statics'dttributable'tb tim6 delay in the near surface edrth-formation directly below each of the plurality of hydrophc;nes, and, alteirnately repeating ieos'(c) and (d) as the marine vessel trve'rses the' line0"f'marine exploration't,o 'produce a' plOrality of seimi c reflection signals and first seismic refraction sign als a16ng'vith- pi ' dra-lit 'of intervening. second seismic efrdction signals,' Accordihg'to tlid invention,' therefore., a seismic energy source and'a seismic energy detector are deploydd'bd the water bottom at a point offsetfrom a line of marine explora-' tion. A marine vessel tows a seismic energy source and a seismic'ma-rine cable including a plurality of hydrophories along that line 6f exploration, and seismic,energy is generated from the towed seismic energy source to produce hot only a seismic reflection signal ,that is detected b ' the'hydr6Phones- on -the' y seismic marine cable bul also a sG-i's-ffiic refrac tion signal that is detected by the 6n-botto'm seismic, detector. The sdismic'refractibn'. signal includes a source static attributable to firne delay in the near surface earth formation directly below th toWed seismic 'energy 1 source. Thereafier, seismic 1 en. ergy is-g'ener ated by.the on-bottom seismic energy so - ur 1 ce to produce a second seismic refraciion signal that is' detected by the hydr9phones.on the seismic marine cable This second seisric de' ' ecei _atic refraction signal -inclu S ver st s attri- butable to tim ' e delay in the ner. surface.earth formation directly below elad'h'of'the dceiving hydrophones.
The first seismic -refraction signaralso in-eludes a receiver static. due -to layering below the on-bottom seismic detector. However by keeping the on-bottoT detector in a fixed position its receiver -static rbmains essentially constant. Similarly the on-bottbm. source has a source static that remainsessentially constant and hence does not interfere with'th6'derivation of static corrections for the towed s'ou"r'ce and receivers.
The alternating- firinds -of iowe:d"and on- bottom seismic ene. r gy source. s is continued as the marine vessel 'trave'rses the'line of marine exploration to produce a -pi(irlit"o'f seismic reflection and first seism. ic i refraction didn'ais along with h plurality of intervening 'second, seismic refraction signals.
According td'a further feature o.f,t.he'.inVen- tion, an interoldtioh- is midde bdtweeh the' 2 GB 2 151 359A 2 receiver statics of successive pairs of the sec ond seismic refraction signals to produce esti mated receiver statics corresponding to the time delays directly below the hydrophones on the marine seismic cable when those hy drophones detect the seismic reflection sig nals. These estimated receiver statics are com bined with the source statics for each seismic energy generation from the towed seismic source to produce a total static correction for each seismic reflection signal.
The present invention will now be described in greater detail by way of example only with reference to the accompanying drawings, in which Figs. 1 and 2 illustrate the method of the invention for determining source and re ceiver statics along a line of marine seismic exploration line; and Figs. 3A-31) represent a sequence of seis mic energy generations for alternating refiec- 85 tion and refraction operations along the line of marine seismic exploration of Fig. 2.
Referring to Fig. 1 of the drawings, a marine seismic vessel 10 traverses a line of marine exploration; the vessel tows a seismic energy source 11 and a seismic detector cable 12 including a plurality of hydrophones 13 spaced along the cable. Seismic energy is generated in the water by the source 1 1 and reflections of such energy from subsurface formations, such as illustrated at 14 below the water bottom 15, are detected by the plurality of hydrophones 13 on the seismic cable 12.
These reflection signals received by the hydro phones 13 are transferred to the marine ves sel 10 through wiring in the cable for record ing and processing. If the hydrophones overlie an anomalous layer of low velocity sediments, an undesirable receiver statics effect will be imposed on the seismic reflection signals.
Also, if the seismic energy source is energized over such a low velocity sediment, undesira ble source statics will be recorded in the reflection signals.
Referring to both Figs. 1 and 2, a seismic energy source 20 and a seismic detector, or hydrophone, 21 are deployed on the water bottom 15 at a position horizontally offset by a distance dfrom the line of exploration 22 being traversed by the vessel 10. Each seismic energy generation from the source 11, in addition to being detected at the hydrophones 13 of detector cable 12 as a seismic reflection signal 16, is also detected at the on-bottom hydrophone 21 as a seismic refraction signal 17. Each seismic energy generation from the on-bottom source 20 is detected at the hydrophones 13 of detector cable 12 as a seismic refraction signal 18. The offset distance d should be large enough to ensure that the refraction signal is the first signal received, and small enough to ensure that the same signal is large enough to be readily detectable. These maximum and minimum distances will vary from area to area depending upon the local velocity structure in the subsurface.
In acco - rdance with the invention, the firings of sources 11 and 20 are alternated and the resulting reflection and second refraction sig- nals received alternately by the hydrophones 13 are utilized to identify source and receiver statics for the particular marine exploration line 22. Referring more particularly to Figs.
3A-313 there are illustrated four alternating seismic firings: a first firing of the towed source 11, a first firing of on-bottom source 20, a second firing of the towed source 11, and a second firing of the on-bottom source 20.
In Fig. 3A, the towed source 11 is fired at shot point location 200 and reflection signals are received at the seismic detector cable 12 by hydrophones 1 3a- 1 3d, for example, at locations 19 3, 19 5, 19 7 and 19 9. Also a first refraction signal is received by the on bottom hydrophone 2 1. As the vessel 10 moves along the line of exploration as seen in Fig. 313 the next seismic energy generation is from the firing of on-bottom source 20 to produce a second refraction signal which is.
received at the seismic detector cable 12 by the same hydrophones 1 3a- 1 3d now posi tioned at locations 19 4, 19 6, 19 8 and 200.
As the vessel 10 continues to move along the line of exploration the next succeeding seismic energy generation is from the firing of towed source 11 at locations 202 as shown in Fig. 3C and reflection signals are received by hydrophones 1 3a- 1 3d now positioned at lo- cations 195, 197, 199 and 201, while a first refraction signal is again received by on-bottorn hydrophone 21. Fig. 31) shows the next succeeding seismic energy generation from the firing of on-bottom source 20 with hydro- phones 1 3a1 3d positioned at locations 19 6, 198, 200 and 202 for receiving the resulting second seismic refraction signal.
In accordance with the operations of Figs. 3A and 3C low velocity layer statics for source locations 200 and 202 respectively are determined by comparing the reflection signals recorded by hydrophones 1 3a- 1 3d with the first refraction signals recorded by the onbottom hydrophone 21.
When the on-bottom source 20 is fired, the hydrophones 1 3a-1 3d have advanced along the line of exploration from their locations during the preceding firing of the towed source 11. For example, with the firing of source 11 from locations 200 and 202, hydrophone 1 3d is positioned at locations 193 and 195 respectively for receiving reflection signals. With the intervening firings of the onbottom source 20, hydrophone 1 3d is posi- tioned at location 194 and then at location 196 for the receiving of the second refraction signals. By interpolation the low velocity layer statics for receiver locations 19 3 and 19 5 can be estimated by averaging the receiver statics components determined for the preceding and 3 GB 2 151 359A 3 following second refraction signals. For example, the receiver statics for location 193 is estimated by averaging the measured re ceiver statics for locations 192 and 194.
Likewise the receiver statics for location 195 is estimated by averaging the measured re ceiver statics for locations 194 and 196.
These measured receiver statics are deter mined by estimating a velocity-depth funcion and calculating a travel time function. The velocity function may be measured by shoot ing conventional refraction lines in adjacent areas which are essentially static free or by analysis of the observed data gathered in the actual survey. Such analysis includes the de term,ination of a best fit function for travel time versus offset and the determination of static shifts until the best fit value for a particular offset is obtained. Such time shifts may be either positive or negative. When such a travel time function has been obtained, source statics can be derived by calculating the appropriate travel time that would be expected for a source to on-bottom receiver distance corresponding to that for a static free 90 seismic refraction signal and subtracting it from that travel time actually observed. The same. process is carried out for each on botto'm source shot and towed receiver posi tion. In this manner total source and receiver statics are identified for each seismic reflec tion signal. Corrections to the recorded seis mic reflection signals can then be carried out by removing the distortions caused by such source and receiver statics introduced by the low velocity layers.
The seismic exploration system may be of the type described in U.S. Patent 4,146,870 in which a seismic energy source and a seis mic detector cable are towed through the water along a line of exploration. One type of suitable seismic energy source for producing repetitive pulses of seismic energy is the pneumatic acoustic source described in U.S.
Patent 3,506,085, and an on-bottom seismic receiver system that is particularly suitable for use for refraction measurements is described in U.S. Patent 4,422,164.
Claims (7)
1. A method of marine seismic exploration comprising the steps of:
(a) fixing a seismic energy source and a seismic energy detector on the water bottom at a point offset from a line of marine explora- 120 tion; (b) traversing the line of marine exploration with a marine vessel towing a seismic energy source and a seismic marine cable including a plurality of spaced hydrophones; (c) generating seismic energy from the towed seismic energy source to produce a seismic reflection signal that is detected by the plurality of hydrophones on the seismic marine cable and a first seismic refraction signal that, is detected.by the fixed s-eisrriic energy detector, the first seismic refraction signal including a source sthtics attributable to time delay in the near surface earth formation directly below the towed seismic energy source; (d) subsequently generating seismic energy from the fixed seismic energy source to produce a second seismic refraction signal that is detected by each of the plurality of hydrophones on the seismic marine cable, the second seismic refraction signal including a receiver statics attributable to time delay in the near surface earth formation directly below each of the pluarlity of hydrophones; and (e) alternately repeating steps (c) and (d) as the marine vessel traverses the line of marine exploration to produce a plurality of seismic reflection signals and first seismic refraction signals along with a plurality of intervening second seismic refraction signals.
2. A method according to claim 1 including the further steps of:
(f) interpolating between the receiver statics of successive pairs of the second seismic refraction signals to produce estimated receiver statics corresponding to the time delays directly below the plurality of hydrophones when the hydrophones detect the seismic reflection signals, and (g) combining the estimated receiver statics with the source statics for each seismic energy generation from the towed seismic energy source to produce a total static correction for each of the plurality of seismic reflection signals.
3. A method according to claim 2, wherein the step of interpolating between receiver statics of successive pairs of second seismic refraction signals includes the interpolation between the successive pairs of second seismic refraction signals.
4. A method according to claim 2, wherein the receiver statics of the second seismic refraction signals are determined by comparing the second seismic refraction signals to static-free seismic refraction signals obtained from an adjacent non-low velocity layer earth area.
5. A method according to claim 2, wherein the receiver statics of the second seismic refraction signals are determined by determining a bestfit function for travel time versus offset and determining static shifts until the best-fit value is obtained for the particular offset.
6. A method according to claim 2, wherein the source statics of the seismic reflection signals are determined by compar- ing the first seismic refraction signals to staticfree seismic refraction signals.
7. A method according to claim 6, wherein the comparison is carried out by determining the travel time that would be expected for a source to on-bottom receiver 4 GB 2 151 359A 4 distance corresponding to that for a static free seismic refraction signal and subtracting it from the travel time actually observed.
Printed in the United Kingdom for Her Majesty's Stationery Office, Dd 8818935, 1985, 4235. Published at The Patent Office, 25 Southampton Buildings. London. WC2A 1 AY. from which copies may be obtained.
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| US06/560,660 US4581724A (en) | 1983-12-12 | 1983-12-12 | Method for determining source and receiver statics in marine seismic exploration |
Publications (3)
| Publication Number | Publication Date |
|---|---|
| GB8429259D0 GB8429259D0 (en) | 1984-12-27 |
| GB2151359A true GB2151359A (en) | 1985-07-17 |
| GB2151359B GB2151359B (en) | 1986-11-12 |
Family
ID=24238771
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| GB08429259A Expired GB2151359B (en) | 1983-12-12 | 1984-11-20 | Method for determining source and receiver statics in marine seismic exploration |
Country Status (4)
| Country | Link |
|---|---|
| US (1) | US4581724A (en) |
| BR (1) | BR8406262A (en) |
| GB (1) | GB2151359B (en) |
| MY (1) | MY100383A (en) |
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| EP0548384A1 (en) * | 1990-06-26 | 1993-06-30 | CHEVRON U.S.A. Inc. | Method of improving the seismic resolution of geologic structures |
Families Citing this family (12)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US4695984A (en) * | 1984-12-24 | 1987-09-22 | Exxon Production Research Company | Method for establishing a surface consistent correction for the effects of the low velocity layer in seismic data processing |
| US4759001A (en) * | 1987-03-27 | 1988-07-19 | Mobil Oil Corporation | Termination apparatus for a marine streamer employing a flexible load bearing outer hosewall |
| US4775962A (en) * | 1987-03-27 | 1988-10-04 | Mobil Oil Corporation | Marine seismic streamer employing variable aperture flow through spacers |
| US4736345A (en) * | 1987-03-27 | 1988-04-05 | Mobil Oil Corporation | Compliant spacer for a marine seismic streamer |
| US4737937A (en) * | 1987-03-27 | 1988-04-12 | Mobil Oil Corporation | Marine seismic streamer employing variable hydrophone density |
| US4935903A (en) * | 1989-05-30 | 1990-06-19 | Halliburton Geophysical Services, Inc. | Reinforcement of surface seismic wavefields |
| US4937793A (en) * | 1989-05-30 | 1990-06-26 | Halliburton Geophysical Services, Inc. | Processing method for marine seismic surveying utilizing dual streamers |
| EG19158A (en) * | 1989-08-25 | 1996-02-29 | Halliburton Geophys Service | System for attenuation of water-column reverberation |
| US4984218A (en) * | 1990-04-26 | 1991-01-08 | Mobil Oil Corporation | Marine acoustic array configured for tow noise reduction |
| US5774416A (en) * | 1995-04-07 | 1998-06-30 | Pgs, Tensor, Inc. | Method and device for attenuating water column reverberations using co-located hydrophones and geophones in ocean bottom seismic processing |
| US5621699A (en) * | 1995-07-07 | 1997-04-15 | Pgs Ocean Bottom Seismic, Inc. | Apparatus and method of calibrating vertical particle velocity detector and pressure detector in a sea-floor cable with in-situ passive monitoring |
| US5754492A (en) * | 1996-02-12 | 1998-05-19 | Pgs Tensor, Inc. | Method of reverberation removal from seismic data and removal of dual sensor coupling errors |
Family Cites Families (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| US3943484A (en) * | 1973-11-26 | 1976-03-09 | Avance Oil & Gas Company, Inc. | Method of attenuating unwanted seismic reflections in underwater seismic exploration |
| US4415997A (en) * | 1981-11-12 | 1983-11-15 | Mobil Oil Corporation | Method for determining source and receiver statics in marine seismic exploration |
| US4516227A (en) * | 1981-12-04 | 1985-05-07 | Marathon Oil Company | Subocean bottom explosive seismic system |
-
1983
- 1983-12-12 US US06/560,660 patent/US4581724A/en not_active Expired - Fee Related
-
1984
- 1984-11-20 GB GB08429259A patent/GB2151359B/en not_active Expired
- 1984-12-07 BR BR8406262A patent/BR8406262A/en not_active IP Right Cessation
-
1987
- 1987-05-15 MY MYPI87000661A patent/MY100383A/en unknown
Cited By (1)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| EP0548384A1 (en) * | 1990-06-26 | 1993-06-30 | CHEVRON U.S.A. Inc. | Method of improving the seismic resolution of geologic structures |
Also Published As
| Publication number | Publication date |
|---|---|
| GB2151359B (en) | 1986-11-12 |
| GB8429259D0 (en) | 1984-12-27 |
| US4581724A (en) | 1986-04-08 |
| MY100383A (en) | 1990-09-17 |
| BR8406262A (en) | 1985-10-01 |
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Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| PCNP | Patent ceased through non-payment of renewal fee |